Systems and methods for addition of fuel additives to control turbine corrosion

ABSTRACT

A system comprises a gas turbine engine including a compressor, combustor, gas turbine, the combustor including a plurality of late lean fuel injectors; and wash system configured to be attached to and in fluid communication with the a plurality of late lean fuel injectors of the combustor. The wash system includes a water source supplying water; a first fluid source supplying a first fluid; a mixing chamber in communication with the water source and first fluid source; a water pump to pump water to the mixing chamber; a first fluid pump to pump the first fluid to the mixing chamber; a fluid line in fluid communication with the mixing chamber and at least one of the plurality of late lean fuel injectors so fluid from the mixing chamber is injected into the combustor at late lean fuel injectors. The wash system is operated with the gas turbine engine off-line.

TECHNICAL FIELD

The present disclosure relates generally to gas turbine engines, andmore particularly, relates to wash systems and related methods forcleaning of internal components of a gas turbine engine.

BACKGROUND

As a gas turbine engine system operates, airborne contaminants that arenot captured by the inlet air filtration system may accumulate naturallyor form complex compounds with combustion byproducts and bond to variousinternal metallic components of the engine, such as the blades and thevanes of internal components. These internal metallic components mayinclude but are not limited to the gas turbine and the compressor.Although the gas turbine engine system may include an inlet airfiltration system, a certain degree of contaminant accumulation may beunavoidable and may depend on various environmental conditions at thesite of operation. Common contaminants may include small amounts of dustand debris that pass through the inlet air filtration system as well asun-filterable hydrocarbon-based materials such as smoke, soot, grease,oil film, and organic vapors. Accumulated contaminants on, for example,the blades and vanes may restrict airflow through the compressor and mayshift the airfoil pattern. In this manner, such accumulation maycompromise cooling passages and adversely affect the performance andefficiency of the compressor or turbine section and thus the overallperformance and efficiency of the gas turbine engine system. Sucheffects may decrease power output, increase fuel consumption, and/orincrease operating costs.

To reduce contaminant accumulation, the gas turbine engine operating andmaintenance regime may include the utilization of a water wash procedurefor removing contaminating particles from, for example, the compressorblades and vanes. An on-line water wash protocol may be used to removecontaminant particles from compressor blades and vanes via a flow ofwater, such as demineralized water, while the gas turbine engine systemis operating at full speed and at a predetermined load. The on-linewater wash protocol may deliver water upstream of the compressor via aninstalled manifold including nozzles positioned about a bellmouth of thecompressor. The nozzles may create a spray mist of water droplets inthis region of relatively low velocity air, and the negative pressureproduced by the operating compressor may draw the spray mist intocontact with the compressor blades and vanes for contaminant removal.

An off-line water wash protocol may be used in a similar manner toremove contaminating particles via a sequential flow of water anddetergent while the gas turbine engine system is shut down or operatingat a turning gear speed and is not loaded. Known off-line water washsystems may sequentially deliver the flow of water and detergentupstream of the compressor via an off-line manifold including nozzlespositioned about a bellmouth of the compressor. In certain applications,a water wash system may be configured to operate in either an on-linemode or an off-line mode. In this manner, on-line washes may be carriedout periodically to increase performance and efficiency of the gasturbine engine system when the operating schedule does not permitshutdown time to perform a more effective off-line wash. The frequencyand duration of on-line and off-line washes may vary depending on thedegree of contaminant accumulation and environmental conditions at thesite of operation.

Although conventional water wash systems and methods may be effective inremoving contaminants from the blades and vanes of early compressorstages, such systems and methods often are less effective in removingcontaminants from the higher numbered stages of blades and vanes of thegas turbine because the flow of water and detergent (if any) injectedabout the bellmouth of the compressor sometimes has limited reach. Gasturbine hot gas path components, including but not limited to, gasturbine blades and nozzles, shrouds may still have some contamination.Moreover, following a wash with such systems and methods, residualamounts of the water and detergent may remain on the blades and vanes.Remaining water and/or detergent may adversely affect subsequent restartand operation of the gas turbine engine system. Depending on the idletime after wash, the residual amounts of water and detergent also mayfacilitate surface rusting, corrosion, or subsequent accumulation ofcontaminants on the compressor blades and vanes and/or gas turbineblades and vanes, and on uncoated combustion components along the hotgas flow path. Further, the performance gain provided by conventionalwater wash systems and methods may be of limited duration, necessitatingfrequent washes carried out with the water wash systems to maintainadequate performance, which ultimately may increase total operatingcosts of the gas turbine engine system.

BRIEF DESCRIPTION

All aspects, examples and features mentioned below can be combined inany technically possible way.

An aspect of the disclosure provides a system that includes a gasturbine engine, the gas turbine engine including a compressor, acombustor, a gas turbine, the combustor including a plurality of latelean fuel injectors supplied with secondary fuel to an interior of thecombustor; and a wash system configured to be attached to and in fluidcommunication with the a plurality of late lean fuel injectors of thecombustor. The wash system includes a water source supplying water; afirst fluid source supplying a first fluid; a mixing chamber incommunication with the water source and the first fluid source; a waterpump configured to pump the water to the mixing chamber; a first fluidpump configured to pump the first fluid to the mixing chamber; a fluidline configured to be in fluid communication with the mixing chamber andat least one of the plurality of late lean fuel injectors such that afluid from the mixing chamber including the water, the first fluid, or amixture thereof is injected into the combustor at at least one of theplurality of late lean fuel injectors. The wash system is operated withthe gas turbine engine in an off-line mode.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source includes a detergent source, andwherein the first fluid includes a detergent.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source includes an anti-static solutionsource, and wherein the first fluid includes an anti-static solution.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source includes a mixture ofdemineralized/deionized water and at least one of magnesium (Mg),yttrium (Y), or detergent.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the mixture of demineralized/deionized water and magnesium(Mg) Mg), yttrium (Y), or detergent removes vanadium from internalcomponents of the gas turbine engine.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the mixture of demineralized/deionized water and magnesium(Mg), yttrium (Y), or detergent is provided as a solution or as a foam.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the mixing chamber includes one or more angled counter flownozzles therein, the one or more angled counter flow nozzles extendinginto the mixing chamber at an angle with respect to a central axis ofthe mixing chamber and configured to inject the first fluid at the anglein a direction counter to a flow of the water in the mixing chamber.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the water source is in communication with the mixing chambervia a water source line and water pump.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source is in communication with the mixingchamber via a first fluid source line and first fluid pump.

Another aspect of the disclosure includes any of the preceding aspects,and, further including a controller, the controller being in operativecommunication with the water pump and the first fluid pump, wherein thecontroller is configured to regulate a flow of the water and the firstfluid through the fluid line to a plurality of late lean fuel injectors.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the controller further includes at least one flow controlvalve positioned in fluid line, the at least one flow control valve isin communication with the controller for enabling actuation of the atleast one flow control valve between at least open and closed positions,the actuation caused by the controller.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the controller further includes at least one flow sensor,positioned in fluid line, the at least one flow sensor in communicationwith the controller for sensing flow in the fluid line.

An aspect of the disclosure provides a method of washing an off-line gasturbine engine, the gas turbine engine including a compressor, acombustor, a gas turbine, the combustor including a plurality of latelean fuel injectors supplied with secondary fuel to an interior of thecombustor. The method includes supplying water from a water source to amixing chamber of a wash system; supplying a first fluid from a firstfluid source to the mixing chamber of the wash system; supplying thewater and first fluid to the mixing chamber including pumping water fromthe water source and pumping the first fluid from the first fluidsource; and injecting fluid from the mixing chamber to at least one ofthe plurality of late lean fuel injectors.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source includes a detergent source, andwherein the first fluid includes a detergent.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source includes an anti-static solutionsource, and wherein the first fluid includes an anti-static solution.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source includes a mixture ofdemineralized/deionized water and at least one of magnesium (Mg),yttrium (Y), or detergent.

Another aspect of the disclosure includes any of the preceding aspects,and the method including removing vanadium from internal metalliccomponents of the gas turbine engine by the mixture ofdemineralized/deionized water and magnesium (Mg), yttrium (Y), ordetergent.

Another aspect of the disclosure includes any of the preceding aspects,and the method including providing the mixture ofdemineralized/deionized water and magnesium (Mg), yttrium (Y), ordetergent as a solution or as a foam.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the mixing chamber includes one or more angled counter flownozzles therein, the one or more angled counter flow nozzles extendinginto the mixing chamber at an angle with respect to a central axis ofthe mixing chamber and to inject the first fluid at the angle in adirection counter to a flow of the water in the mixing chamber, andfurther including mixing the water and the first fluid using the one ormore angled counter flow nozzles.

Another aspect of the disclosure includes any of the preceding aspects,and the gas turbine engine further includes a controller, the controllerin operative communication with the water pump, the first fluid pump,and the fluid line, and further including regulating a flow of the waterand the first fluid through the fluid line to a plurality of late leanfuel injectors.

An aspect of the disclosure provides a gas turbine engine system. Thegas turbine engine system includes a gas turbine engine, the gas turbineengine including a compressor, a combustor, a gas turbine, the combustorincluding a plurality of late lean fuel injectors supplied withsecondary fuel to an interior of the combustor; a wash system configuredto be attached to and in fluid communication with the a plurality oflate lean fuel injectors of the combustor. The wash system includes awater source including water; a first fluid source including a firstfluid, the first fluid providing vanadium ash and vanadium depositmitigation and removal from internal components of the gas turbine; amixing chamber in communication with the water source and the firstfluid source; a water pump configured to pump the water to the mixingchamber; a first fluid pump configured to pump the first fluid to themixing chamber; a fluid line configured to be in fluid communicationwith the mixing chamber and at least one of the plurality of late leanfuel injectors such that a fluid from the mixing chamber including thewater, the first fluid, or a mixture thereof is injected into thecombustor at at least one of the plurality of late lean fuel injectors,wherein the mixture is injected while the gas turbine engine is on-line.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source includes a mixture ofdemineralized/deionized water and at least one of magnesium (Mg),yttrium (Y), or detergent injected into the combustor at at least one ofthe plurality of late lean fuel injectors, and the mixture ofdemineralized/deionized water and at least one of magnesium (Mg),yttrium (Y), or detergent as vanadium ash formation mitigant isdelivered to the late lean fuel injectors and then conveyed to internalcomponents of gas turbine with a flow of combustion gases from thecombustor to the gas turbine.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the mixture of demineralized/deionized water and magnesium(Mg) Mg), yttrium (Y), or detergent removes vanadium from internalmetallic components of the gas turbine engine.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the mixture of demineralized/deionized water and magnesium(Mg), yttrium (Y), or detergent is provided as water-based or as foam.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the mixing chamber includes one or more angled counter flownozzles therein, the one or more angled counter flow nozzles extendinginto the mixing chamber at an angle with respect to a central axis ofthe mixing chamber and configured to inject the first fluid at the anglein a direction counter to a flow of the water in the mixing chamber.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the water source is in communication with the mixing chambervia a water source line and a water pump.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source is in communication with the mixingchamber via a first fluid source line and a first fluid pump.

Another aspect of the disclosure includes any of the preceding aspects,and further including an independent microprocessor based controller,the controller being in operative communication with the water pump andthe first fluid pump, wherein the controller is configured to regulate aflow of the water and the first fluid through the fluid line to aplurality of late lean fuel injectors.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the controller further includes at least one flow controlvalve positioned in the fluid line, the at least one flow control valvein communication with the controller for enabling actuation of the atleast one flow control valve between at least open and closed positions,the actuation caused by the controller.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the controller further includes at least one flow sensor,positioned in the fluid line, the at least one flow sensor incommunication with the controller for sensing flow in the fluid line.

An aspect of the disclosure provides a method of washing an on-line gasturbine engine, the gas turbine engine including a compressor, acombustor, a gas turbine, and the combustor including a plurality oflate lean fuel injectors supplied with secondary fuel to an interior ofthe combustor. The method includes supplying water from a water sourceto a mixing chamber of a wash system; supplying a first fluid from afirst fluid source to the mixing chamber of the wash system, the firstfluid providing vanadium ash and vanadium deposit mitigation and removalfrom internal components of the gas turbine; supplying the water and thefirst fluid to the mixing chamber including pumping water from the watersource and pumping the first fluid from the first fluid source; andinjecting fluid from the mixing chamber to at least one of the pluralityof late lean fuel injectors while the gas turbine engine is on-line.Another aspect of the disclosure includes any of the preceding aspects,and wherein the first fluid source includes a mixture ofdemineralized/deionized water and at least one of magnesium (Mg),yttrium (Y), or detergent.

Another aspect of the disclosure includes any of the preceding aspects,and the method includes removing vanadium from internal components ofthe gas turbine engine using the mixture of demineralized/deionizedwater and magnesium (Mg) Mg), yttrium (Y), or detergent.

Another aspect of the disclosure includes any of the preceding aspects,and the method including providing the mixture ofdemineralized/deionized water and magnesium (Mg) Mg), yttrium (Y), ordetergent as water-based or as foam.

Another aspect of the disclosure includes any of the preceding aspects,and wherein the mixing chamber includes one or more angled counter flownozzles therein, the one or more angled counter flow nozzles extendinginto the mixing chamber at an angle with respect to a central axis ofthe mixing chamber to inject the first fluid at the angle in a directioncounter to a flow of the water in the mixing chamber.

Another aspect of the disclosure includes any of the preceding aspects,and, the gas turbine engine further including a controller, thecontroller in operative communication with the water pump, the firstfluid pump, and the fluid line, and further comprising regulating a flowof the water and the first fluid through the fluid line to a pluralityof late lean fuel injectors using the controller.

Another aspect of the disclosure includes any of the preceding aspects,and the method further includes forming a vanadium based ash componentmagnesium orthovanadate [3MgO.V₂O₅] by treating deposited vanadium at anappropriate Mg/V ratio, wherein magnesium orthovanadate does not meltand remains in a solid state on the internal components of the gasturbine during operation of the gas turbine.

Another aspect of the disclosure includes any of the preceding aspects,and the method further includes forming an additional ash component, theadditional ash component including water soluble magnesium sulfate(MgSO₄), wherein MgSO₄ is removed from the gas turbine engine systemthrough water washing.

An aspect of the disclosure provides a gas turbine engine systemincluding a gas turbine engine. The gas turbine engine includes acompressor, a combustor, a gas turbine, the combustor including aplurality of late lean fuel injectors supplied with secondary fuel to aninterior of the combustor. The gas turbine engine system also includes awash system configured to be attached to and in fluid communication withthe plurality of late lean fuel injectors of the combustor. The washsystem includes a water source supplying water; a water pump configuredto pump the water; an anti-corrosion agent fluid source including asupply of an anti-corrosion agent including a polyamine corrosioninhibitor; an anti-corrosion agent supply piping, the anti-corrosionagent supply piping being in fluid communication with the anti-corrosionagent fluid source; a mixing chamber in communication with the watersource and the anti-corrosion agent source, the mixing chamber being influid communication with the water supply piping and the anti-corrosionagent supply piping, the mixing chamber being configured to receivewater from the water supply piping and the anti-corrosion agent from theanti-corrosion agent supply piping to produce an anti-corrosion mixture,the anti-corrosion mixture including a mixture of the anti-corrosionagent and water; a water pump configured to pump the water to the mixingchamber; a first fluid pump configured to pump the anti-corrosion agentto the mixing chamber; a fluid line configured to be in fluidcommunication with the mixing chamber and at least one of the pluralityof late lean fuel injectors such that a fluid from the mixing chamberincluding the water, the anti-corrosion agent fluid, or a mixturethereof is injected into the combustor at at least one of the pluralityof late lean fuel injectors. The mixture is injected while the gasturbine engine is off-line.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes an organic compound.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes two or more primaryamino groups, NH₂.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes a volatileneutralizing amine, the volatile neutralizing amine configured toneutralize acidic contaminants and elevate pH of the mixture into analkaline range, wherein the mixture with the volatile neutralizing amineprovides protective metal oxide coatings on internal components of thegas turbine.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes at least one ofcycloheaxylamine, morpholine, monoethanolamine,N-9-Octadecenyl-1,3-propanediamine, 9-octadecen-1-amine, (Z)-1-5,dimethylaminepropylamine (DMPA), diethylaminoethanol (DEAE), andcombinations thereof.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes an amount of theanti-corrosion agent/inhibitor in the anti-corrosion mixture in a rangefrom about 50 ppm to about 800 ppm.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes an amount of theanti-corrosion agent/inhibitor in the anti-corrosion mixture in a rangefrom about 100 ppm to about 500 ppm.

Another aspect of the disclosure includes any of the preceding aspects,wherein the mixing chamber includes one or more angled counter flownozzles therein, the one or more angled counter flow nozzles extendinginto the mixing chamber at an angle with respect to a central axis ofthe mixing chamber and configured to inject the polyamine corrosioninhibitor at the angle in a direction counter to a flow of the water inthe mixing chamber.

Another aspect of the disclosure includes any of the preceding aspects,wherein the water source is in communication with the mixing chamber viaa water source line and a water pump.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor source is in communicationwith the mixing chamber via a polyamine corrosion inhibitor line and apolyamine corrosion inhibitor pump.

Another aspect of the disclosure includes any of the preceding aspects,further including a controller, the controller being in operativecommunication with the water pump and the polyamine corrosion inhibitorpump, wherein the controller is configured to regulate a flow of themixture of water and the polyamine corrosion inhibitor through the fluidline to a plurality of late lean fuel injectors.

Another aspect of the disclosure includes any of the preceding aspects,wherein the controller further includes at least one flow control valvepositioned in fluid line, the at least one flow control valve incommunication with the controller for enabling actuation of the at leastone flow control valve between at least open and closed positions, theactuation caused by the controller.

Another aspect of the disclosure includes any of the preceding aspects,wherein the controller further includes at least one flow sensor,positioned in the fluid line, the at least one flow sensor incommunication with the controller for sensing flow in the fluid line.

An aspect of the disclosure provides a method of washing an off-line gasturbine engine. The gas turbine engine including a compressor, acombustor, a gas turbine, the combustor including a plurality of latelean fuel injectors supplied with secondary fuel to an interior of thecombustor. The method includes supplying water from a water source to amixing chamber of a wash system; supplying an anti-corrosion agent froman anti-corrosion agent fluid source through an anti-corrosion agentsupply piping to the mixing chamber, the anti-corrosion agent includinga polyamine corrosion inhibitor, the anti-corrosion agent supply pipingbeing in fluid communication with the anti-corrosion agent fluid source;supplying the water and anti-corrosion agent fluid to the mixing chamberincluding pumping water from the water source and pumping theanti-corrosion agent fluid from the anti-corrosion agent fluid source,the mixing chamber configured to receive water from the water supplypiping and the anti-corrosion agent fluid from the anti-corrosion agentsupply piping to produce an anti-corrosion mixture, the anti-corrosionmixture including a mixture of the anti-corrosion agent and water; andinjecting the anti-corrosion mixture from the mixing chamber to at leastone of the plurality of late lean fuel injectors while the gas turbineengine is off-line.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes an organic compound.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes two or more primaryamino groups, NH₂.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes a volatileneutralizing amine, the volatile neutralizing amine configured toneutralize acidic contaminants and elevate pH of the mixture into analkaline range, wherein the mixture with the volatile neutralizing aminecan provide protective metal oxide coatings on internal components ofthe gas turbine.

Another aspect of the disclosure includes any of the preceding aspects,wherein the polyamine corrosion inhibitor includes at least one ofcycloheaxylamine, morpholine, monoethanolamine,N-9-Octadecenyl-1,3-propanediamine, 9-octadecen-1-amine, (Z)-1-5,dimethylaminepropylamine (DMPA), diethylaminoethanol (DEAE), andcombinations thereof.

Another aspect of the disclosure includes any of the preceding aspects,wherein the mixing chamber includes one or more angled counter flownozzles therein, the one or more angled counter flow nozzles extendinginto the mixing chamber at an angle with respect to a central axis ofthe mixing chamber to inject the first fluid at the angle in a directioncounter to a flow of the water in the mixing chamber.

Another aspect of the disclosure includes any of the preceding aspects,the gas turbine engine further including a controller, the controller inoperative communication with the water pump and the first fluid pump,wherein the method includes the controller regulating a flow of thewater and the anti-corrosion agent fluid through the fluid line to aplurality of late lean fuel injectors.

Two or more aspects described in this disclosure, including thosedescribed in this summary section, may be combined to formimplementations not specifically described herein.

The details of one or more implementations are set forth in theaccompanying drawings and the description below. Other features, objectsand advantages will be apparent from the description and drawings, andfrom the claims.

BRIEF DESCRIPTION OF THE DRAWINGS

These and other features of this disclosure will be more readilyunderstood from the following detailed description of the variousaspects of the disclosure taken in conjunction with the accompanyingdrawings that depict various embodiments of the disclosure, in which:

FIG. 1 is a schematic diagram of a gas turbine engine system including acompressor, a combustor, a turbine, and a load, according to embodimentsof the disclosure;

FIG. 2 is a partial perspective view of a portion of the gas turbineengine system of FIG. 1 , showing portions of the compressor, thecombustor, and the turbine, according to embodiments of the disclosure;

FIG. 3 is a schematic diagram of a gas turbine engine system including agas turbine engine, late lean injectors, a wash system, and a systemcontroller, according to embodiments of the disclosure;

FIG. 4 is a schematic diagram of a wash system leading to late leaninjectors of a combustor, according to embodiments of the disclosure;

FIG. 5 is a detailed schematic diagram of a mixing chamber and relatedsupply lines as may be used in the wash system, according to embodimentsof the disclosure;

FIG. 6 is a schematic diagram illustrating details of a wash system,according to embodiments of the disclosure; and

FIGS. 7, 8, and 9 are flowcharts (flow diagrams) of wash methodology asmay be carried out with the wash system for a gas turbine engine system,according to embodiments of the disclosure.

It is noted that the drawings of the disclosure are not necessarily toscale. The drawings are intended to depict only typical aspects of thedisclosure and therefore should not be considered as limiting the scopeof the disclosure. In the drawings, like numbering represents likeelements between the drawings.

DETAILED DESCRIPTION

As an initial matter, in order to clearly describe the subject matter ofthe current disclosure, it will become necessary to select certainterminology when referring to and describing relevant machine componentswithin a turbine system, such as but not limited to a gas turbine enginesystem. To the extent possible, common industry terminology will be usedand employed in a manner consistent with its accepted meaning. Unlessotherwise stated, such terminology should be given a broadinterpretation consistent with the context of the present applicationand the scope of the appended claims. Those of ordinary skill in the artwill appreciate that often a particular component may be referred tousing several different or overlapping terms. What may be describedherein as being a single part may include and be referenced in anothercontext as consisting of multiple components. Alternatively, what may bedescribed herein as including multiple components may be referred toelsewhere as a single part.

In addition, several descriptive terms may be used regularly herein, andit should prove helpful to define these terms at the onset of thissection. These terms and their definitions, unless stated otherwise, areas follows. As used herein, “downstream” and “upstream” are terms thatindicate a direction relative to the flow of a fluid, such as theworking fluid through the turbine engine or, for example, the flow ofair through the combustor or coolant through one of the turbine'scomponent systems. The term “downstream” corresponds to the direction offlow of the fluid, and the term “upstream” refers to the directionopposite to the flow (i.e., the direction from which the floworiginates). The terms “forward” and “aft,” without any furtherspecificity, refer to directions, with “forward” referring to the frontor compressor end of the engine, and “aft” referring to the rearwardsection of the turbomachine.

It is often required to describe parts that are disposed at differingradial positions with regard to a center axis. The term “radial” refersto movement or position perpendicular to an axis. For example, if afirst component resides closer to the axis than a second component, itwill be stated herein that the first component is “radially inward” or“inboard” of the second component. If, on the other hand, the firstcomponent resides further from the axis than the second component, itmay be stated herein that the first component is “radially outward” or“outboard” of the second component. The term “axial” refers to movementor position parallel to an axis. Finally, the term “circumferential”refers to movement or position around an axis. It will be appreciatedthat such terms may be applied in relation to the center axis of theturbine.

In addition, several descriptive terms may be used regularly herein, asdescribed below. The terms “first,” “second,” and “third,” may be usedinterchangeably to distinguish one component from another and are notintended to signify location or importance of the individual components.

The terminology used herein is for the purpose of describing particularembodiments only and is not intended to be limiting of the disclosure.As used herein, the singular forms “a,” “an,” and “the” are intended toinclude the plural forms as well, unless the context clearly indicatesotherwise. It will be further understood that the terms “comprises”and/or “comprising,” when used in this specification, specify thepresence of stated features, integers, steps, operations, elements,and/or components but do not preclude the presence or addition of one ormore other features, integers, steps, operations, elements, components,and/or groups thereof. “Optional” or “optionally” means that thesubsequently described event or circumstance may or may not occur orthat the subsequently describe component or element may or may not bepresent, and that the description includes instances where the eventoccurs or the component is present and instances where it does not or isnot present.

Where an element or layer is referred to as being “on,” “engaged to,”“connected to” or “coupled to” another element or layer, it may bedirectly on, engaged to, connected to, or coupled to the other elementor layer, or intervening elements or layers may be present. In contrast,when an element is referred to as being “directly on,” “directly engagedto,” “directly connected to” or “directly coupled to” another element orlayer, there may be no intervening elements or layers present. Otherwords used to describe the relationship between elements should beinterpreted in a like fashion (e.g., “between” versus “directlybetween,” “adjacent” versus “directly adjacent,” etc.). As used herein,the term “and/or” includes any and all combinations of one or more ofthe associated listed items.

Gas turbine fuels can range from natural gas and high-quality liquiddistillate fuels to crude oils and low-grade refinery residues andcombustible residual gases from some processes like steel manufacturing.For some gas turbine fuels, there may be additives needed for efficiencyand effective operation of a gas turbine. Additives can vary based onthe fuel type and the nature and quantity of contaminants from allsources that enter the gas turbine. Additional factors for additiveselection, such as but not limited to firing temperature and originalequipment manufacturer (OEM) specifications, are also considered.

Many fuel additives are intended to control high temperature corrosionand ash fouling of gas turbine hot gas path section components. Severaldifferent corrosion mechanisms can occur during combustion, andgenerally may be attributed to formation of low melting point ashdeposits. These ash deposits may originate from trace metal impuritiesin gas turbine fuels. For example, heavy fuel oils (HFOs), including butnot limited to crude oils and residual-grade fuel oils, typicallycontain quantities of vanadium (V). Vanadium is a naturally occurringcomponent of petroleum.

During combustion, fuels including vanadium may create vanadic ashdeposits. Vanadic ash deposits are formed mainly of vanadium pentoxide(V₂O₅), and have a “low” melting point of about 675° C. (1247° F.). Attypical gas turbine operating temperatures, vanadic ash deposits aremolten. Being molten, vanadic ash deposits may accelerate surfaceoxidation rate of hot gas path components of gas turbines. Gas turbinehot gas path components include, but are not limited to combustionliners, transition pieces, turbine nozzles, turbine blades, and turbinevanes. Other trace metal impurities, such as lead, and zinc, may alsoinitiate high temperature corrosion, by similar mechanisms.

Alkali metal impurities, namely sodium (Na) and potassium (K), can alsocause high temperature corrosion, known as sulfidation corrosion.Sulfidation corrosion involves formation of sodium sulfates, throughreaction with fuel sulfur. Sulfidation corrosion results ininter-granular pitting of gas turbine hot gas path components, which ismetallurgically undesirable.

In certain regions, especially the Middle East, vanadium and sodiumimpurities are common in fuel. Thus, lower melting point ash depositscan readily form in a gas turbine system in this region. Accordingly,with non-treated or additive free gas turbine fuel from these regions, arisk of high temperature corrosion in a gas turbine system is increased.

Sodium and potassium salts are water-soluble and can be removed (or atleast reduced to within acceptable specification limits) by on-sitetreatment processes. These on-site treatments processes are known as“fuel washing.”

Distillate-grade fuels are not typically washed at the gas turbine powerplant. Distillate-grade fuels may often be delivered containing someamount of contamination, such as but not limited to sodiumcontamination. Moreover, vanadium and other oil-soluble trace metalscannot be removed by fuel washing. Corrosion inhibition processes andtreatments to remove some contamination, such as but not limited tovanadium contamination, may have to be achieved using chemicaladditives, as described herein.

Liquid fuels are not the only source of ash-forming impurities orcontamination. Sodium salts and other contaminants can be found in gasturbine fuel and thusly enter gas turbine engine systems in variousmanners. Contaminants may enter a gas turbine engine system from gasturbine fuel, from compressor inlet air, from water and steam that maybe injected for nitrogen oxide (NOx) control, from power augmentationsteps, and/or from other such sources. Thus, risk of contamination fromnon-fuel sources should also be considered in gas turbine engine systemapplications.

Fuel additives that include magnesium (Mg) can be used to controlvanadic ash deposits and vanadic oxidation. Magnesium can modify vanadicash composition and increase vanadic ash melting points, which reducesthe possibility of molten vanadium causing issues. Through combinationwith V₂O₅ at an appropriate magnesium-to-vanadium (Mg/V) treatmentratio, magnesium ortho-vanadate [3MgO.V₂O₅] is formed as a new ashcomponent. 3MgO.V₂O₅ has a high melting point of about 1243° C. (2269°F.). Accordingly, with 3MgO.V₂O₅ vanadic ash corrosion of a gas turbineengine system is limited and controlled. By ensuring that vanadic ash asa combustion ash does not melt and remains in a solid state on gasturbine blades and vanes, vanadic ash corrosion can be reduced.

Through reaction with sulfur in gas turbine fuel, magnesium inhibitionmechanisms through formation of 3MgO.V₂O₅ also generate magnesiumsulfate (MgSO₄) as an additional ash component. MgSO₄ is water-soluble.Thus, MgSO₄ facilitates removal of combustion ash through periodic waterwashing of gas turbine hot gas path components. The removal ofcombustion ash can enable power to be recovered that may have been lostdue to ash formation on gas turbine hot gas path components.

Chromium (Cr) additives for gas turbine fuels can inhibit sulfidationcorrosion promoted by alkali metal contaminants, such as, but notlimited to, sodium and potassium. Chromium additives have also beenshown to reduce ash fouling. Chromium additive ash fouling reduction mayinvolve formation of volatile compounds with contaminants, which passthrough the gas turbine without depositing on hot gas path components.Moreover, additives can include chromium alone, or can be in combinationwith magnesium and other constituents. Additives containing silicon (Si)can also be added to provide added corrosion protection and improved ashfriability from hot gas path components of a gas turbine system.

Magnesium additives are of a sulfonate type chemistry. Sulfonate typechemistry in ash formation is resistant to hydrolysis. Any tendency forgel formation of sulfonate type additives because of water contact withsulfonate ash formations is extremely low. Thus, sulfonate typechemistry additives can mitigate plugging of gas turbine systemcomponents, including but not limited to, filters, flow dividers,nozzles, blades, and/or fuel nozzles.

Sulfonate type additives also enable high reactivity during combustion.The high reactivity may permit magnesium to be consumed more efficientlyduring vanadium inhibition. This high reactivity may be due to extremelysmall particle sizes of sulfonate type additives, where the particlesize of sulfonate type additives are about 5 times smaller thanmagnesium carboxylate (C₁₀H₁₂MgN₂O₆) particles. Accordingly, sulfonatemagnesium additives can be safely added to gas turbine fuel, therebyensuring protection without over-treatment.

As used in this application, “offline washing” is where the gas turbineis spun by an external crank, and the gas turbine is in a cooled stateusing cranking speed. When a gas turbine is off-line, it is not burningfuel or supplying power. As embodied by the disclosure, conversely, anonline process is conducted with the gas turbine being at an operatingtemperature, burning fuel and supplying power.

Referring now to the drawings, in which like numerals refer to likeelements throughout the several views, FIG. 1 illustrates a schematicview of gas turbine engine system or gas turbine engine system 10, asembodied by the disclosure. Gas turbine engine system 10 may include acompressor 15. Compressor 15 compresses an incoming flow of air 20 afterair 20 flows through inlet filter house 15′. Compressor 15 delivers thecompressed flow of air 20 to a combustor 25. Combustor 25 mixes thecompressed flow of air 20 with a pressurized flow of fuel 30 and ignitesthe mixture to create a flow of combustion gases 35. Although only asingle combustor 25 is shown, gas turbine engine system 10 may includeany number of combustors 25. The flow of combustion gases 35 is in turndelivered to a gas turbine 40. The flow of combustion gases 35 drivesgas turbine 40 to produce mechanical work. Mechanical work produced ingas turbine 40 drives compressor 15 via a shaft 45 and an external load50, such as but not limited to, an electrical generator and the like.

Gas turbine fuels can range from natural gas and high-quality liquiddistillate fuels to crude oils and low-grade refinery residues. Gasturbine engine system 10 may be any one of a number of different gasturbine engines offered by General Electric Company of Schenectady,N.Y., including but not limited to, those such as a 7 or a 9 seriesheavy duty gas turbine engine, an H class series heavy duty gas turbineengine, such as an HA gas turbine engine, and the like. The gas turbineengine system 10 may have different configurations and may use othertypes of components. Other gas turbine engines may also be used herein.Multiple gas turbine engines, other types of turbines, and other typesof power generation equipment also are also within the scope of theembodiments described herein.

FIG. 2 is an example of a compressor 15 as may be used with gas turbineengine system 10 and the like. Compressor 15 may include a number ofstages 55. Although eighteen stages 55 are shown, any number of stages55 may be used. Each stage 55 includes a number of circumferentiallyarranged rotating blades 60. Any number of blades 60 may be used. Blades60 may be mounted onto a rotor wheel 65. Rotor wheel 65 may be coupledto shaft 45 (FIG. 1 ) for rotation therewith. Each stage 55 also mayinclude a number of circumferentially arranged stationary vanes 67. Anynumber of vanes 67 may be used. Vanes 67 may be mounted within an outercasing 70. Outer casing 70 may extend from a bellmouth 75 towards gasturbine 40. The flow of air 20 (FIG. 1 ) thus enters compressor 15 aboutbellmouth 75 and is compressed through blades 60 and vanes 67 of stages55 before flowing to combustor 25 (FIG. 1 ). Bellmouth 75 may beprovided with water wash injection nozzles (not illustrated for ease ofunderstanding and clarity) for applying water and/or detergents tocompressor blades 60 and vanes 67 of stages 55. However, the waterand/or detergent may not flow to all blades 60 and vanes 67 of stages 55of compressor 15. Moreover, compressor water wash systems do not providea direct path to gas turbine components, including but not limited tohot gas path components including stage one nozzles (S1N) and stage 2nozzles (S2N), as well as associated wheel space cavities of gas turbine40 (FIG. 1 ) that may get contamination thereon. Accordingly, asembodied by the disclosure, providing injection points for washing gasturbine components, including but not limited to hot gas path componentsincluding stage 1 nozzles (S1N) and stage 2 nozzles (S2N), as well asassociated wheel space cavities, may be obtained by locating injectioncloser to the gas turbine itself.

With reference to FIG. 3 , a combustor 25 includes a first interior 21in which a first fuel supplied thereto by fuel circuit is combustible,and a transition zone 43 to gas turbine 40. Gas turbine 40 includesrotating turbine blades and nozzles in stages, into which products of atleast the combustion are receivable to power rotation of turbine blades.The transition zone 43 fluidly couples combustor 25 to turbine 40.Transition zone 43 includes a second interior 41 into which a secondfuel is supplied to further the combustion. As shown, combustor 25 andtransition zone 43 combine with one another to generally have a form ofa head end 11.

As illustrated in FIG. 3 , head end 11 may include multiple premixingnozzles 12. However, other head end 11 configurations are possible. Itis understood that versions of other head end 11 configurations may belate lean injection (LLI) or axial fuel staging (AFS) combustors(to bedescribed hereinafter with respect to secondary fuel injected intocombustor 25 AT fuel injectors 60) compatible. For purposes of thisdescription, LLI and AFS are similar and equivalent. An LLI compatiblecombustor is a combustor with either an exit temperature that exceedsabout 2500° F. or about 1370° C., or a combustor that handles fuels withcomponents that are more reactive than methane with a hot side residencetime greater than 10 milliseconds (ms).

A plurality of late lean fuel injectors 60 are structurally supported byan exterior wall of transition zone 43 or by an exterior wall of asleeve 42 around transition zone 43 and extend into second interior 41to varying depths. With this configuration, fuel injectors 60 may beconfigured to provide late lean injection (LLI) fuel staging capability.That is, fuel injectors 60 are each configured to supply a second fuel(i.e., LLI fuel) to second interior 41 by, e.g., fuel injection in adirection that is generally transverse to a predominant flow direction.Fuel injectors 60 may inject fuel in this manner through transition zone43, in any one of a single axial stage, multiple axial stages, a singleaxial circumferential stage, and/or multiple axial circumferentialstages. Conditions within combustor 25 and transition zone 43 are thusstaged to create local zones of stable combustion.

As embodied by the disclosure, an aspect provides a single axial stagethat includes operating a single fuel injector 60. Alternatively,multiple axial stages may be operated at multiple axial locations attransition zone 43. Further, embodiments may include a single axialcircumferential stage operating fuel injector 60 disposed around acircumference of a single axial location of transition zone 43. In otherembodiments, multiple axial circumferential stages may be operating fuelinjectors 60 disposed around a circumference of the transition zone 43at multiple axial locations.

Here, where multiple fuel injectors 60 are disposed around acircumference of transition zone 43, fuel injectors 60 may be spacedsubstantially evenly or unevenly from one another. As a non-limitingillustration, eight or ten fuel injectors 60 may be disposed at aparticular circumferential stage, and for example with two, three, fouror five or more fuel injectors 60 installed with varying degrees ofseparation from one another around transition zone 43. Also, wheremultiple fuel injectors 60 are disposed at multiple axial stages oftransition zone 43, fuel injectors 60 may be in-line and/or staggeredwith respect to one another.

During operations of gas turbine engine system 10, each fuel injector 60may be jointly or separately activated or deactivated to form one of thesingle axial stage, the multiple axial stages, the single axialcircumferential stage, and the multiple axial circumferential stages.Thus, in an aspect of the embodiments, fuel injectors 60 each may besupplied with LLI fuel by a fuel injector 60 port or valve 61(hereinafter “valve” 61) disposed between a corresponding fuel injector60 and a fuel circuit. Valve 61 signal communicates with a controller 80that sends a signal to valve 61 that causes the valve 61 to open orclose and to thereby activate or deactivate corresponding fuel injector60.

Thus, if each fuel injector 60 is to be simultaneously activated (i.e.,multiple axial circumferential stages), controller 80 signals to each ofthe valves 61 to open and thereby activate each of the fuel injectors60. Conversely, if each fuel injector 60 of a particular axial stage oftransition zone 43 is to be activated (i.e., single axialcircumferential stage), controller 80 includes an element (e.g., but notlimited to an electro-mechanical transducer) configured to convert anelectrical signal from controller 80 to a corresponding adjustment tovalves 60, 61. Signals to each of valves 61 may correspond to only thefuel injectors 60 of the single axial circumferential stage to open andthereby activate each of the fuel injectors 60. Of course, this controlsystem is merely illustrative and it is understood that multiplecombinations of fuel injector configurations are possible and that othersystems and methods for controlling the activation and deactivation ofat least one of fuel injectors 60 are available.

In accordance with another aspect of the disclosure, a method ofoperating a gas turbine engine system 10, in which a turbine 40 isfluidly coupled to a combustor 25 by a transition zone 43 interposedtherebetween, is provided. The method includes supplying a first fuel toa first interior 21 within combustor 25, combusting the first fuel infirst interior 21 within combustor 25, supplying a second fuel to secondinterior 41 within transition zone 43 in any one of a single axialstage, multiple axial stages, a single axial circumferential stage andmultiple axial circumferential stages, and combusting the second fueland a stream of combustion products, received from first interior 21, insecond interior 41 within the transition zone.

Supplying of the second fuel to second interior 41 in the single axialstage may include activating a single fuel injector 60. Supplying thesecond fuel to the second interior 41 in the multiple axial stages mayinclude activating multiple fuel injectors 60 respectively disposed atmultiple axial locations of the transition zone 43. Supplying the secondfuel to second interior 41 in the single axial circumferential stagealso includes activating multiple fuel injectors 60 respectivelydisposed around a circumference of transition zone 43 at a single axiallocation thereof. Additionally, supplying the second fuel to secondinterior 41 in the multiple axial circumferential stages includesactivating multiple fuel injectors 60 disposed around a circumference oftransition zone 43 at multiple axial locations thereof.

FIG. 4 shows a wash system 100 as embodied by the disclosure. Washsystem 100 may include a water source 110. The water source 110 may haveany size, shape, or configuration. The water source 110 may have avolume of water 120 therein. Wash system 100 also may include adetergent source 130. The detergent source 130 may have any size, shape,volume, or other configuration. The detergent source 130 may have asupply of a detergent 140 therein. The detergent 140 may be any type ofcleaning solution. The detergent 140 may be diluted with the water 120in a predetermined ratio.

In another aspect of the embodiments, wash system 100 also may include achemical source 150. Chemical source 150 may have any size, shape, orconfiguration. In certain embodiments, chemical source 150 may have avolume of an anti-static solution 160 therein. Anti-static solution 160may be any type of anti-static fluid. Anti-static solution 160 may bediluted with the water 120 in a predetermined ratio. Water source 110,detergent source 130, and/or chemical source 150 may be positioned on awash skid 165 in whole or in part. Wash skid 165 may be mobile and mayhave any size, shape, or configuration. Other components and otherconfigurations may be used herein. Each source 110, 130 and 150 arereferred to in general as a “source” and may provide particular washmaterials, such as, but not limited to, being a water source 110; adetergent source 130; and a solution or chemical source 150. Each source110, 130, and 150 may include level sensors (not illustrated in FIG. 3 ,see FIG. 6 ) to provide an indication of source content level. Moreover,as used herein, source(s) 110, 130, and 150 may be referred generally asa “source” or alternatively, with respect to particulars of the washmaterial(s) it may include.

Wash system 100 also may include a mixing chamber 170. Mixing chamber170 may be used to mix detergent 140 with water 120, or anti-staticsolution 160 with water 120. Other combinations of fluids may also beused. Non-diluted fluids also may be used herein. FIG. 5 illustrates anon-limiting illustrative mixing chamber 170. Mixing chamber 170 mayinclude one or more of angled counter flow nozzles 180 for the flow ofdetergent 140 and/or anti-static solution 160 or other type of secondaryflows. Flow of detergent 140 or anti-static solution 160 may be injectedat a non-diametrically opposed or counter angle via angled counter flownozzles 180 into an incoming flow of water or other type of primary flowfor good mixing therein without the use of moving parts. Effectivemixing also may be provided by injecting flow of detergent 140 oranti-static solution 160 at a higher pressure as compared to flow ofwater 120. Mixing chamber 170 may have any size, shape, orconfiguration. The one or more angled counter flow nozzles 180 extendinto the mixing chamber at an angle with respect to a central axis ofmixing chamber 170 and can be configured to inject a first fluid at anangle in a direction counter to a flow of the water in mixing chamber170.

As shown in FIG. 4 , water source 110 may be in communication withmixing chamber 170 via a water line 190. Water line 190 may have a waterpump thereon. Water pump may be, e.g., of conventional design. Waterline 190 may have a pair of water line isolation valves 210 thereon.Detergent source 130 may be in communication with mixing chamber 170 viaa detergent line 220. Detergent line 220 may have a detergent pump 230thereon. Detergent pump 230 may be, e.g., of conventional design.Detergent line 220 may have a pair of detergent line isolation valves240 thereon. Anti-static solution source 160 may be in communicationwith mixing chamber 170 via an anti-static solution line 250.Anti-static solution line 250 may have an anti-static solution pump 260thereon. Anti-static solution pump 260 may be of conventional design.Anti-static solution line 250 may have a pair of anti-static solutionline isolation valves 270 thereon. Other components and otherconfigurations may be used herein.

Wash system 100 also may include a conduit or line 340, i.e., an outputline from mixing chamber 170. In this example, with respect to FIGS. 3and 4 , line 340 leads from skid 165 to one or more of valves 61 forlate lean injection (axial fuel staging) in combustor 25. Thus, washmaterials, such as at least one of water 120, detergent 140, anti-staticsolution 160, and passivation solution (to be described hereinafter) canbe fed to combustor 25. When fed to combustor 25 at valves 61 for latelean injection, wash materials are proximate hot gas path components ofgas turbine 40, and in particular S1N of gas turbine 40. Therefore, asat least one of washing, detergent, anti-static, and passivationsolution materials can proceed to late lean injectors valves 61 of gasturbine 40 (FIG. 4 ) via combustion gas 35 (FIG. 1 ) streams to act onand clean gas turbine 40 components, including but not limited to,blades and nozzles of gas turbine 40.

With respect to FIGS. 4 and 6 , a wash controller 380 may operate washsystem 100. Wash controller 380 may provide at least one of water 120,detergent 140, anti-static solution 160, and/or passivation solution (asdescribed hereinafter) to mixing chamber 170 and then to combustor 25 inappropriate ratios thereof. Wash controller 380 may be any type ofprogrammable logic device (as discussed hereinafter) and may be incommunication with or part of an overall control system of gas turbineengine system 10. Specifically, wash controller 380 may control valveinterlocks, fluid levels, pump operation, connectivity signals, flowsensors, temperature, pressure, timing, and the like, as discussedherein. Various types of sensors (such as but not limited to,thermometers, flow meters, pressure sensors, and the like.) may be usedherein to provide feedback to wash controller 380. Access to washcontroller 380 and operation parameters herein may be restricted toensure adequate cleaning and coverage.

In use, wash skid 165 with fluid sources 110, 140, 150 may be positionedadjacent gas turbine engine system 10 (FIG. 1 ). Alternatively, thefluid sources 110, 140, 150 may be more permanently located nearby inwhole or in part, to gas turbine engine system 10.

In certain aspects of the embodiments, wash controller 380 may determinea ratio of water 120 to detergent 130. Wash controller 380 may activatewater pump 220 and/or detergent pump 230 to pump corresponding volumesof water 120 and detergent 140 to mixing chamber 170. A portion of adetergent/water mixture from mixing chamber 170 may flow through conduitor line 340 to a connection with one or more of valves 61 of combustor25 for resultant flow to S1N of gas turbine 40. Flow may occur with gasturbine 40 off-line with gas turbine 40 under cranking power to permitflow from combustor 25 to gas turbine 40. Also, the flow of mixturethrough conduit or line 340 may occur when gas turbine 40 is on-linewith mixture flowing with combustion gas 35 to gas turbine 40. Washcontroller 380 then may turn pumps 220,230 off once the predeterminedvolume of detergent/water mixture 390 has been injected into valves 61of combustor 25. Wash controller 380 may again activate water pump 220to provide a water rinse, if requested. A volume of water 120 in a rinsemay vary.

Wash system 100 can provide improved cleaning and application ofanti-static solution 160 throughout combustor 25 including throughvalves 61 to be fed to gas turbine 40, including washing and treating,for example, stage one and two nozzles (S1N)(S2N) and associated wheelspace cavities. The increased coverage of anti-static solution 160 mayenhance the ability to suppress the electrostatic attraction of materialon the gas turbine blades as well as the stationary nozzles with areduced propensity to form deposits, such as ash contaminants.Anti-static coverage may provide water wash recovered gas turbineoperational gains for a longer period of time. Accordingly, gas turbineengine system 10 may have improved sustainable performancecharacteristics. Moreover, wash system 100 uses existing LLI (axial fuelstaging) piping of combustor 25 such that reconstruction or retrofittingis not required.

Wash system 100 also may provide the ability to control an injectionrate and quantity of anti-static solution 160 to ensure adequatecoverage to gas turbine 40 and including stage one and two nozzles (S1Nand S2N) and associated wheel space cavities. Wash controller 380 mayvary the ratio and volume of a detergent/water mixture and/oranti-static solution/water mixture that may be delivered to combustor25.

Embodiments of the disclosure may provide off-line cleaning of combustor25, gas turbine 40, and especially stage one and two nozzles (S1N andS2N) and associated wheel space cavities of gas turbine 40. Withreference to FIG. 6 , where like reference numerals refer to likeelements, and a further discussion of those elements is omitted forclarity and brevity, a schematic illustration of a gas turbine enginesystem 10 is illustrated with a wash system 100. Off-line cleaning asembodied by the disclosure provides anti-oxidant cleaning to stage oneand two nozzles (S1N and S2N) and associated wheel space cavities of gasturbine 40. Wash system 100 provides a mixture ofdemineralized/deionized water and at least one of magnesium (Mg),yttrium (Y) for vanadium mitigation, as described here, or detergentfrom wash system 100 injected into combustor 25 through late leaninjection (axial fuel staging) valves 61. Moreover, water and at leastone of magnesium (Mg), yttrium (Y), or detergent from wash system 100can be delivered to the off-line gas turbine engine system 10 as a foamor water, for example, in a homogeneous stream at late lean injectorvalves 61.

In aspects of the embodiments, anti-oxidant cleaner, water andmagnesium, is provided for targeted stage one and two nozzles (S1N andS2N) and associated wheel space cavities in situ cleaning in gas turbine40. Wash system 100 and the associated process use existing LLI (axialfuel staging) valves 61 to dispense a predetermined mixture ofdemineralized water and magnesium into combustor 25. As embodied by thedisclosure, wash system 100, when applied to a gas turbine engine system10 can: remove vanadium, including vanadium in ash form, from a stageone and stage two nozzle (S1N) and (S2N) and associated wheel spacecavities and/or other internal components of gas turbine 40; enhance theability to retain recovered performance of gas turbine engine system 10for longer durations after cleaning; mitigate against nozzle pluggingand rust formation/oxidation in gas turbine engine system 10 andespecially in gas turbine 40; clean and remove ash formations; clean andremove oxidation and particulate from combustor surfaces; provideincreased plant reliability and efficiency that is attributable toreduction in cooling air path plugging; and improve reliability of gasturbine engine systems operating on heavy fuel oils.

With reference to FIGS. 4-7 , wash system 100 provides wash materials tocombustor 25 and then to stage one and two nozzles (S1N and S2N) andassociated wheel space cavities for in situ cleaning in gas turbine 40when gas turbine engine system 10 is offline. It is to be noted thatcompressor washing through providing wash materials at the bellmouth 75(FIG. 2 ) of compressor 15 (FIG. 1 ) may still be provided with anyoperation and aspect described herein, as embodied by the disclosure.However, the exact system, process, and other details with respect tocompressor washing are not germane to aspects of the embodiments, andfurther discussion will be omitted.

Conduit or line 190 extends from water supply 120 and line 250 extendsfrom supply 160 (such as a chemical supply of, for example, awater-based magnesium sulphite), and lines 190 and 250 meet at mixingchamber 170. From mixing chamber 170, line 340 extends to combustor 25.Line 340 may include at least one of chemical sensor 341 for detectingchemical characteristics of mixture, flow senor 342, modulating orcontrol valve 343, temperature sensor 344, and filter 345. Each of atleast one of chemical sensor 341, flow senor 342, modulating valve 343,temperature sensor 344, as well as motor 220 and chemical source 150level sensor 162, communicate with controller 380. Accordingly,controller 380 may regulate and manage operation of wash system 100 inits off-line operation in accordance with the embodiments herein.

Another aspect of the embodiments provides cleaning of combustor 25, gasturbine 40, and in particular stage one and stage two nozzles (S1N) and(S2N) and associated wheelspace cavities of gas turbine 40 andadditionally ash formation mitigation, during operation of gas turbineengine system 10. Reference can again be made to FIGS. 4-6 , wash system100 provides wash materials to combustor 25 and then stage one and twonozzles (S1N and S2N) and associated wheel space cavities for in situcleaning in gas turbine 40, and also provides ash formation mitigationmaterials to gas turbine engine system 10 during operation of gasturbine engine system 10.

As embodied by the disclosure, this aspect of the wash system 100provides and distributes low temperature ash formation mitigants withwash materials from combustor 25 and its late lean injection valves ornozzles 61, and then to gas turbine 40 internal components, includingstage one and two nozzles (S1N and S2N) and associated wheel spacecavities of gas turbine 40. Wash system 100, as per this aspect of theembodiments, provides a mixture of demineralized/deionized water fromwash system 100 injected into combustor 25 through late lean injection(axial fuel staging) valves 61. Also, wash system 100 may also provideyttrium, magnesium or any now known or later developed low temperatureash formation mitigant, in sources 130 and/or 150 from wash system 100into existing late lean injection (axial fuel staging) valves or nozzles61 of combustor 25. Non-limiting types of low temperature ash formationmitigant may include water or oil based yttrium or magnesium. As notedherein, wash system 100 provides wash water, such asdemineralized/deionized water, and low temperature ash formationmitigant into combustor 25 LLI (axial fuel staging) valves 61. Asembodied by the disclosure, the late lean injection (axial fuel staging)valves 61 are ahead of stage one and two nozzles (S1N) and (S2N) andassociated wheel space cavities in gas turbine 40 and flow of combustiongases 35 is in turn delivered to gas turbine 40. Low temperature ashformation mitigant delivered to LLI (axial fuel staging) valves 61 isconveyed to internal components of gas turbine 40 with the flow 35 ofcombustion gases.

As embodied by the disclosure, method and system for ash formationmitigation and cleaning during operation of gas turbine engine system 10can: reduce a rate of ash formation on a gas turbine stage one and twonozzles (S1N and S2N), associated wheel space cavities and other gasturbine internal turbine components; enhance the ability to retainrecovered performance of gas turbine engine system 10 for longerdurations after cleaning; mitigate against nozzle plugging, hotcorrosion/oxidation, aero shape/profile deformation that may be due toplugging; enhances the ability to meet and exceed degradation guaranteebonus opportunity, especially in gas turbine engines that operate onheavy fuel oxide (HFO) gas turbines and gas turbine units that rely ongas fuel with high concentrations of vanadium and other ash formingimpurities; increased plant reliability, output and efficiency that canbe attributable to reduction in nozzle effective area and changes toblade aerodynamic profiles; clean and remove ash formations; clean andremove oxidation and particulate from combustor surfaces; and provideincreased plant reliability and efficiency that is attributable toreduction in cooling air path plugging.

As embodied by the disclosure, wash system 100 for ash formationmitigation during gas turbine engine system 10 (FIG. 1 ) operation canbe illustrated by the configuration of FIG. 6 . Line 190 extends fromwater supply 110 and line 250 extends from chemical source 150, forexample, chemical source 150 in this aspect includes a volume ofyttrium, magnesium or another low temperature ash formation mitigant,and lines 190 and 250 meet at mixing chamber 170. From mixing chamber170, line 340 extends to combustor 25. Line 340 may include at least oneof chemical sensor 341, flow senor 342, modulating valve 343,temperature sensor 344, and filter 345. Each of at least one of chemicalsensor 341, flow senor 342, modulating valve 343, temperature sensor344, as well as motor 200, chemical source 150 level sensor 162communicate with controller 380. Accordingly, controller 380 mayregulate and mange operation of wash system 100 in its off-lineoperation in accordance with the embodiments herein.

A further aspect of the embodiments provides off-line cleaning andpassivation of combustor 25, gas turbine 40, and especially stage oneand stage two nozzles (S1N) and (S2N) and associated wheel spacecavities of gas turbine 40. With continued reference to FIGS. 6 and 7 ,where like reference numerals refer to like elements, and a furtherdiscussion of those elements is omitted for clarity and brevity, aschematic illustration of a gas turbine engine system 10 is illustratedwith a wash system 100. Off-line cleaning as embodied by the disclosure,provides anti-oxidant cleaning and passivation of combustor 25, gasturbine 40, and especially stage 1 nozzle of gas turbine 40 to stage 1nozzle of gas turbine 40. Wash system 100 provides a mixture ofdemineralized/deionized water and at least one of a polyamine ormagnesium (Mg) from wash system 100 injected into combustor 25 throughlate lean injection (axial fuel staging) valves 61.

In this aspect of the embodiments, mixture of demineralized/deionizedwater and at least one of a polyamine or magnesium is provided fortargeted stage one and two nozzles (S1N and S2N) and associated wheelspace cavities in situ cleaning in gas turbine 40, including stage oneand two nozzles (S1N and S2N) and associated wheel space cavities of gasturbine 40, when gas turbine 40 is off-line. Wash system 100 and theassociated process use existing late lean injection (axial fuel staging)valves 61 to dispense a predetermined mixture of demineralized/deionizedwater and at least one of a polyamine or magnesium into combustor 25,from where predetermined mixture of demineralized water and magnesiumcan flow into gas turbine 40. As embodied by the disclosure, wash system100 of FIG. 6 , when applied to a gas turbine engine system 10 can coatinternal gas turbine components to passivate them. Included in theinternal gas turbine components that are coated and passivated are stageone and stage two nozzles (S1N) and (S2N) plus associated wheel spacecavities and/or other internal components of gas turbine 40.Passivation, as embodied by the disclosure, can: enhance the ability toretain recovered performance of gas turbine engine system 10 for longerdurations after cleaning; mitigate against nozzle plugging and rustformation/oxidation in gas turbine engine system 10 and especially ingas turbine 40; clean and remove ash formations; may reduce severity andfrequency to perform degradation based maintenance; clean and removeoxidation and particulate from combustor surfaces; provide increasedplant reliability and efficiency that is attributable to reduction incooling air path plugging; reduce potential crack propagation andsurface degradation of stage one and two nozzles (S1N and S2N) andassociated wheel space cavities and/or other gas turbine components; andimprove reliability gas turbine engines operating on heavy fuel oils.

With reference to FIGS. 4-7 , wash system 100 provides mixeddemineralized/deionized water and at least one of a polyamine ormagnesium to combustor 25 and then for S1N in situ cleaning in gasturbine 40 when gas turbine engine system 10 is offline. Being offlinemeans it is to be noted that compressor washing through providing washmaterials at the bellmouth 75 (FIG. 2 ) of compressor 15 (FIG. 1 ) maystill be provided with any operation and aspect described herein, asembodied by the disclosure. However, the exact system, process, andother details with respect to compressor washing are not germane toaspects of the embodiments, and further discussion will be omitted.

Line 190 extends from water supply 110 and line 250 extends fromchemical supply 150, for example, a mixture of demineralized/deionizedwater and at least one of a polyamine or magnesium, and lines 190 and250 meet at mixing chamber 170. From mixing chamber 170, line 340extends to combustor 25. Line 340 may include at least one of chemicalsensor 341, flow senor 342, modulating valve 343, temperature sensor344, and filter 345. Each of at least one of chemical sensor 341, flowsenor 342, modulating valve 343, temperature sensor 344, as well asmotor 200 and chemical source 150 level sensor 162 communicate withcontroller 380. Accordingly, controller 380 may regulate and mangeoperation of wash system 100 in its off-line operation in accordancewith the embodiments herein.

As embodied by the disclosure, the passivation material, for example butnot limited to at least one of a polyamine or magnesium, can be providedin a liquid form or a foam form. Aspects of the disclosure enable themixture of demineralized/deionized water and at least one of a polyamineor magnesium to flow from late lean injection valves or nozzles to stageone and two nozzles (S1N and S2N) and associated wheel space cavities ofgas turbine 40 for passivation of stage one and two nozzles (S1N andS2N) and associated wheel space cavities, and other internal gas turbinecomponents.

An anti-corrosion mixture, as embodied by the disclosure, can include ananti-corrosion agent and water. Anti-corrosion mixture can be suppliedas an aqueous solution (e.g., using water as a liquid carrier) tocombustor 25 and then to gas turbine 40 sections of gas turbine enginesystem 10. Anti-corrosion mixture can coat gas turbine engine componentstherein with a metal passivation coating which mitigates corrosion onthose coated parts.

Magnesium sulfate can be used as a cleaning agent, in accordance withcertain aspects of the embodiments. For applications in which gasturbine engine system 10 employs heavy oil as a fuel, heavy oil can betreated with a vanadium-based corrosion/deposit inhibitor. Avanadium-based corrosion/deposit inhibitor can form slag in gas turbineengine system 10 during operation. Magnesium sulfate may preventformation of vanadium-based slag promoted by the use of crude, heavyoils as a gas turbine fuel. Magnesium sulfate, as a vanadium-basedcorrosion/deposit inhibitor, can be connected to a water-based magnesiumsulfate solution, in certain aspects of the embodiments.

As embodied by the disclosure, anti-corrosion mixture can be pre-mixed(in mixing chamber 170) and supplied to gas turbine engine system 10.Further, anti-corrosion mixture can be provided to combustor 25 throughwashing system 100.

Anti-corrosion mixture imparts corrosion resistance and/or inhibition togas turbine engine system 10 and gas turbine 40 including its stage oneand stage two nozzles (S1N) and (S2N) and associated wheel spacecavities by metal passivation. Metal passivation provides ananti-corrosion coating on the metal and/or metal alloy substrates in gasturbine engine system 10 with which the anti-corrosion mixture, asembodied by the disclosure, comes into contact via entry at late leaninjection valves 61 of combustor 25, as discussed above. A resultantanti-corrosion coating therefore (partially or fully) coats gas turbine40 especially its stage one nozzles, and various metallic hot gas pathcomponents, such as gas turbine blades and other nozzles).

Metal passivation imparts a protective shield to metal and/or metalalloy substrates from environmental factors, such as but not limited to,high temperatures, combustion by-products, debris, etc. exhibited in gasturbine engines by forming a metal oxide layer/coating. Metal oxidelayer/coating protects metal or metal alloy substrate components of gasturbine 40 from corrosive species. Anti-corrosion coatings can be seenas a molecular layer, or on other words, a micro coating. In one aspectof the disclosure, anti-corrosion coating also strengthens bonds in themetal or metal alloy substrate of gas turbine engine system 10. Inanother aspect of the embodiments, significant thermal decomposition ofanti-corrosion coating may be avoided at temperatures below 500° C. Inyet another aspect, successive anti-corrosion treatment cycles can beapplied to the gas turbine engine system 10 using the wash system 100described herein, resulting in a multi-layer anti-corrosion coating.

Anti-corrosion mixtures can include water and an anti-corrosion agent ina particularly selected, predetermined ratio. Any anti-corrosionagent/inhibitor that is suitable to impart an anti-corrosion coating maybe employed. In an embodiment, the anti-corrosion agent is an organicamine. Amine as a corrosion agent/inhibitor by absorbing at themetal/metal oxide surface of components in gas turbine engine system 10,thereby restricting access of potentially corrosive species (e.g.,dissolved oxygen, carbonic acid, chloride/sulfate anions, etc.) at ametal or metal alloy substrate surface of the gas turbine engine system10 component. In another embodiment, the anti-corrosion agent/inhibitorcan be two or more organic amines. In yet another embodiment,anti-corrosion agent/inhibitor may be a polyamine. As used herein, theterm “polyamine” refers to an organic compound having two or moreprimary amino groups, NH₂. In still another embodiment, theanti-corrosion agent/inhibitor further includes a volatile neutralizingamine, which can neutralize acidic contaminants and elevate pH into analkaline range, and with which protective metal oxide coatings areparticularly stable and adherent.

In another aspect of the embodiments, non-limiting examples of theanti-corrosion agent/inhibitor include, but are not limited to,cycloheaxylamine, morpholine, monoethanolamine,N-9-Octadecenyl-1,3-propanediamine, 9-octadecen-1-amine, (Z)-1-5,dimethylaminepropylamine (DMPA), diethylaminoethanol (DEAE), and thelike, and combinations thereof. In a further embodiment, an amount ofthe anti-corrosion agent/inhibitor in the anti-corrosion mixture is from5 parts per million (ppm) to 1000 ppm. In another embodiment, an amountof the anti-corrosion agent/inhibitor in the anti-corrosion mixture isprovided in a range from about 50 ppm to about 800 ppm. In yet anotherembodiment, the amount of the anti-corrosion agent/inhibitor in theanti-corrosion mixture is provided in a range from about 100 ppm toabout 500 ppm.

In a particular aspect of the embodiments, the amount of theanti-corrosion agent/inhibitor in a first anti-corrosion mixturesupplied to late lean injection valves 61 of combustor 25 is from 5 ppmto 1000 ppm.

Anti-corrosion mixtures including water and anti-corrosionagent/inhibitor are introduced into gas turbine engine system 10 via theLLI valves 61, as discussed above, are in an aqueous solution. As usedherein, “aqueous solution” refers to a liquid phase medium. In anembodiment of the disclosure, the aqueous solution is a liquid phasemedium, which is devoid of polyamine gas, water vapor (such as steam),and/or air. Water acts as a liquid carrier for anti-corrosionagent/inhibitor, which is also in a liquid phase. Water thus carriesanti-corrosion agent/inhibitor through piping 340 and into selectedregions of combustor 25 and gas turbine 40, coating the componentstherein with the anti-corrosion coating.

As will be appreciated by one skilled in the art, controller 80 andcontroller 380, as embodied by the disclosure, may be embodied as asystem, method or computer program product. Accordingly, controller 80and controller 380, as embodied by the disclosure, may take the form ofan entirely hardware embodiment, an entirely software embodiment(including firmware, resident software, micro-code, etc.) or anembodiment combining software and hardware aspects that may allgenerally be referred to herein as a “circuit,” “module” or “system.”Furthermore, controller 80 and controller 380, as embodied by thedisclosure, may take the form of a computer program product embodied inany tangible medium of expression having computer-usable program codeembodied in the medium. Additionally, controller 80 and controller 380,as embodied by the disclosure, may take the form of a non-transitorycomputer readable storage medium storing code representative of acomponent according to embodiments of the disclosure.

FIGS. 7-9 are flow diagrams or flow charts for processes, as embodied bythe disclosure. Like steps in each flow chart are represented by likereference step numbers.

With respect to FIG. 7 , the wash process 500 is an off-line process500. In step 501, gas turbine engine system 10 is off-line. Optionalprocess 502 is to wash compressor 15, where the compressor wash can beaccomplished through known systems, either separate from wash system 100as embodied by the disclosure, or in conjunction with wash system 100,as embodied by the disclosure. In off-line process 500, water and theparticular cleansing agent are applied to internal components of gasturbine 40 through late lean injectors 60 of combustor 25. In process500, water and an anti-oxidation agent are applied at step 503 and areapplied to internal components of gas turbine 40 through late leaninjectors 60 of combustor 25.

Process 504 is optional and can apply a rinse and apply detergent toremove contaminants, such as but not limited to slag, ash, oils, and thelike, as needed, and can be applied to internal components of gasturbine 40 through late lean injectors 60 of combustor 25. Process 505is also optional and can apply a rinse, if needed, are applied tointernal components of gas turbine 40 through late lean injectors 60 ofcombustor 25. In process 500, another optional process 506 can apply apassivation treatment (similar to that applied in process 700 describedhereinafter), to internal components of gas turbine 40 through late leaninjectors 60 of combustor 25. Drying at process 507 of gas turbineengine system 10 components can occur for one embodiment of process 500.

As shown in FIG. 8 , process 600 is an on-line wash process. In process601, the gas turbine engine system 10 (FIG. 1 ) is on-line, and anoptional step of washing compressor 15 may occur in process 602. Inprocess 603, water and anti-corrosion agent(s) can be applied tointernal components of gas turbine 40 through LLI(s) 60 of combustor 25.As embodied by the disclosure, magnesium or yttrium can be included asthe anti-corrosion agent to remove vanadium. Moreover, in process 603the water and anti-corrosion agent can be applied as a homogeneousliquid blend or a foam. In process 604, a rinse and detergent can beoptionally applied to remove contaminants, such as but not limited toslag, ash, oils, and the like, as needed, and can be applied to internalcomponents of gas turbine 40 through late lean injectors 60 of combustor25. Process 605 is an optional application of a rinse, if needed,applied to internal components of gas turbine 40 through late leaninjectors 60 of combustor 25. Process 606 is also an optionalapplication of an anti-corrosive or passivation treatment.

Referring to FIG. 9 , in off-line wash process 700, water and theparticular agent are applied to internal components of gas turbine 40through late lean injectors 60 of combustor 25. In process 701, gasturbine engine system 10 is off-line. Optional process 702 is to washcompressor 15, where the compressor wash can be accomplished throughknown systems, either separate from wash system 100 as embodied by thedisclosure, or in conjunction with wash system 100, as embodied by thedisclosure. In process 700, water and an anti-corrosive/passivationtreatment-agent are added at process 703 and are applied to internalcomponents of gas turbine 40 through late lean injectors 60 of combustor25. Process 704 is optional and can apply a rinse and apply detergent toremove contaminants, such as but not limited to slag, ash, oils, and thelike, as needed, and can be applied to internal components of gasturbine 40 through late lean injectors 60 of combustor 25. Process 705is optional and can apply a rinse, if needed, applied to internalcomponents of gas turbine 40 through LLI(s) 60 of combustor 25. Dryingat process 706 of gas turbine engine system 10 components can occur foroff line process 700.

Any combination of one or more computer usable or computer readablemedium/media may be used for controller(s) 80 and 380. Thecomputer-usable or computer-readable medium that may be utilized forcontroller(s) 80 and 380 may include, for example but not limited to, anelectronic, magnetic, optical, electromagnetic, infrared, orsemiconductor system, apparatus, device, or propagation medium. Morespecific examples (a non-exhaustive list) of the computer-readablemedium that may be utilized for one or both of controllers 80 and 180would include the following: an electrical connection having one or morewires, a portable computer diskette, a hard disk, a random access memory(RAM), a read-only memory (ROM), an erasable programmable read-onlymemory (EPROM or Flash memory), an optical fiber, a portable compactdisc read-only memory (CD-ROM), an optical storage device, atransmission media such as those supporting the Internet or an intranet,or a magnetic storage device. Note that the computer-usable orcomputer-readable medium could even be paper or another suitable mediumupon which the program is printed, as the program can be electronicallycaptured, via, for instance, optical scanning of the paper or othermedium, then compiled, interpreted, or otherwise processed in a suitablemanner, if necessary, and then stored in a computer memory. In thecontext of this document, a computer-usable or computer-readable mediummay be any medium that can contain, store, communicate, propagate, ortransport the program for use by or in connection with the instructionexecution system, apparatus, or device. The computer-usable medium mayinclude a propagated data signal with the computer-usable program codeembodied therewith, either in baseband or as part of a carrier wave. Thecomputer usable program code may be transmitted using any appropriatemedium, including but not limited to wireless, wireline, optical fibercable, RF, etc.

Computer program code for carrying out wash operations, as embodied bythe disclosure, may be written in any combination of one or moreprogramming languages, including an object oriented programming languagesuch as Java, Smalltalk, C++ or the like and conventional proceduralprogramming languages, such as the “C” programming language or similarprogramming languages. The program code may execute entirely on theuser's computer, partly on the user's computer, as a stand-alonesoftware package, partly on the user's computer and partly on a remotecomputer or entirely on the remote computer or server. In the latterscenario, the remote computer may be connected to the user's computerthrough any type of network, including a local area network (LAN) or awide area network (WAN), or the connection may be made to an externalcomputer (for example, through the Internet using an Internet ServiceProvider).

The embodiments are described with reference to flowchart illustrationsand/or block diagrams of methods, apparatus (systems) and computerprogram products according to embodiments of the disclosure. It will beunderstood that each block of the flowchart illustrations and/or blockdiagrams, and combinations of blocks in the flowchart illustrationsand/or block diagrams, can be implemented by computer programinstructions. These computer program instructions may be provided to aprocessor of a general purpose computer, special purpose computer, orother programmable data processing apparatus to produce a machine, suchthat the instructions, which execute via the processor of the computeror other programmable data processing apparatus, create means forimplementing the functions/acts specified in the flowchart and/or blockdiagram block or blocks.

These computer program instructions may also be stored in acomputer-readable medium that can direct a computer or otherprogrammable data processing apparatus to function in a particularmanner, such that the instructions stored in the computer-readablemedium produce an article of manufacture including instruction meanswhich implement the function/act specified in the flowchart and/or blockdiagram block or blocks.

The computer program instructions may also be loaded onto a computer orother programmable data processing apparatus to cause a series ofoperational steps to be performed on the computer or other programmableapparatus to produce a computer implemented process such that theinstructions which execute on the computer or other programmableapparatus provide processes for implementing the functions/actsspecified in the flowchart and/or block diagram block or blocks.

The foregoing drawings show some of the processing associated accordingto several embodiments of this disclosure. In this regard, each drawingor block within a flow diagram of the drawings represents a processassociated with embodiments of the method described. It should also benoted that in some alternative implementations, the acts noted in thedrawings or blocks may occur out of the order noted in the figure or,for example, may in fact be executed substantially concurrently or inthe reverse order, depending upon the act involved. Also, one ofordinary skill in the art will recognize that additional blocks thatdescribe the processing may be added.

Approximating language, as used herein throughout the specification andclaims, may be applied to modify any quantitative representation thatcould permissibly vary without resulting in a change in the basicfunction to which it is related. Accordingly, a value modified by a termor terms, such as “about,” “approximately” and “substantially,” are notto be limited to the precise value specified. In at least someinstances, the approximating language may correspond to the precision ofan instrument for measuring the value. Here and throughout thespecification and claims, range limitations may be combined and/orinterchanged; such ranges are identified and include all the sub-rangescontained therein unless context or language indicates otherwise.“Approximately,” as applied to a particular value of a range, applies toboth end values and, unless otherwise dependent on the precision of theinstrument measuring the value, may indicate +/−10% of the statedvalue(s).

The corresponding structures, materials, acts, and equivalents of allmeans or step plus function elements in the claims below are intended toinclude any structure, material, or act for performing the function incombination with other claimed elements as specifically claimed. Thedescription of the present disclosure has been presented for purposes ofillustration and description but is not intended to be exhaustive orlimited to the disclosure in the form disclosed. Many modifications andvariations will be apparent to those of ordinary skill in the artwithout departing from the scope and spirit of the disclosure. Theembodiment was chosen and described in order to explain the principlesof the disclosure and the practical application and to enable others ofordinary skill in the art to understand the disclosure for variousembodiments with various modifications as are suited to the particularuse contemplated.

What is claimed is:
 1. A gas turbine engine system, comprising: a gasturbine engine, the gas turbine engine including a compressor, acombustor, and a gas turbine, the combustor including a plurality oflate lean fuel injectors supplied with a secondary fuel to an interiorof the combustor; and a wash system configured to be attached to and influid communication with the plurality of late lean fuel injectors ofthe combustor, the wash system including: a water source supplyingwater; a first fluid source supplying a first fluid; a mixing chamber incommunication with the water source and the first fluid source; a waterpump configured to pump the water to the mixing chamber; a first fluidpump configured to pump the first fluid to the mixing chamber; a fluidline configured to be in fluid communication with the mixing chamber andat least one of the plurality of late lean fuel injectors such that afluid from the mixing chamber including the water, the first fluid, or amixture thereof is injected into the combustor at at least one of theplurality of late lean fuel injectors, wherein the wash system isoperated with the gas turbine engine in an off-line mode.
 2. The gasturbine engine system of claim 1, wherein the first fluid sourceincludes a detergent source, and wherein the first fluid includes adetergent.
 3. The gas turbine engine system of claim 1, wherein thefirst fluid source includes an anti-static solution source, and whereinthe first fluid includes an anti-static solution.
 4. The gas turbineengine system of claim 1, wherein the first fluid source supplies amixture of demineralized/deionized water and at least one of magnesium(Mg), yttrium (Y), or detergent.
 5. The gas turbine engine system ofclaim 4, wherein the mixture of demineralized/deionized water andmagnesium (Mg) Mg), yttrium (Y), or detergent removes vanadium frominternal components of the gas turbine engine.
 6. The gas turbine enginesystem of claim 4, wherein the mixture of demineralized/deionized waterand magnesium (Mg), yttrium (Y), or detergent is provided as a solutionor as a foam.
 7. The gas turbine engine system of claim 1, wherein themixing chamber includes one or more angled counter flow nozzles therein,the one or more angled counter flow nozzles extending into the mixingchamber at an angle with respect to a central axis of the mixing chamberand configured to inject the first fluid at the angle in a directioncounter to a flow of the water in the mixing chamber.
 8. The gas turbineengine system of claim 1, wherein the water source is in communicationwith the mixing chamber via a water source line and a water pump.
 9. Thegas turbine engine system of claim 1, wherein the first fluid source isin communication with the mixing chamber via a first fluid source lineand a first fluid pump.
 10. The gas turbine engine system of claim 1,further including a controller, the controller being in operativecommunication with the water pump and the first fluid pump, wherein thecontroller is configured to regulate flow of the water and the firstfluid through the fluid line to at least one of the plurality of latelean fuel injectors.
 11. The gas turbine engine system of claim 10,wherein the controller further includes at least one flow control valvepositioned in the fluid line, the at least one flow control valve is incommunication with the controller for enabling actuation of the at leastone flow control valve between at least open and closed positions, theactuation caused by the controller.
 12. The gas turbine engine system ofclaim 10, wherein the controller further includes at least one flowsensor positioned in the fluid line, the at least one flow sensor incommunication with the controller for sensing flow in the fluid line.13. A method of washing an off-line gas turbine engine, the gas turbineengine including a compressor, a combustor, a gas turbine, the combustorincluding a plurality of late lean fuel injectors supplied withsecondary fuel to an interior of the combustor, the method including:supplying water from a water source to a mixing chamber of a washsystem; supplying a first fluid from a first fluid source to the mixingchamber of the wash system; supplying the water and first fluid to themixing chamber including pumping water from the water source and pumpingthe first fluid from the first fluid source; and injecting fluid fromthe mixing chamber to at least one of the plurality of late lean fuelinjectors while the gas turbine engine is off-line.
 14. The method ofclaim 13, wherein the first fluid source includes a detergent source,and wherein the first fluid includes a detergent.
 15. The method ofclaim 13, wherein the first fluid source includes an anti-staticsolution source, and wherein the first fluid includes an anti-staticsolution.
 16. The method of claim 13, wherein the first fluid sourceincludes a mixture of demineralized/deionized water and at least one ofmagnesium (Mg), yttrium (Y), or detergent.
 17. The method of claim 16,wherein the injecting causes removal of vanadium from internalcomponents of the gas turbine engine by the mixture ofdemineralized/deionized water and magnesium (Mg), yttrium (Y), ordetergent.
 18. The method of claim 16, wherein the mixture ofdemineralized/deionized water and magnesium (Mg), yttrium (Y), ordetergent is a solution or a foam.
 19. The method of claim 13, whereinthe mixing chamber includes one or more angled counter flow nozzlestherein, the one or more angled counter flow nozzles extending into themixing chamber at an angle with respect to a central axis of the mixingchamber to inject the first fluid at the angle in a direction counter toa flow of the water in the mixing chamber, further including mixing thewater and the first fluid using the one or more angled counter flownozzles.
 20. The method of claim 13, wherein the gas turbine enginefurther includes a controller, the controller in operative communicationwith the water pump, the first fluid pump, and the fluid line, andfurther including regulating a flow of the water and the first fluidthrough the fluid line to a plurality of late lean fuel injectors, usingthe controller.